Connection locator in a power aggregation system for distributed electric resources

ABSTRACT

A connection in a power aggregation system for distributed electric resources is located by establishing, by way of a computer network, a communication between a mobile electric resource and a network-connected device, the mobile electric resource including one or more processors including a processor to control power flow, obtaining, with the one or more processors, a unique identifier associated with the network-connected device, transmitting, with the one or more processors, information regarding the mobile electric resource to a remote server, determining, with the one or more processors or the remote server, a location of the mobile electric resource from the unique identifier, determining at least one power connection location from the determined location, and charging the mobile electric resource with the determined at least one power connection location.

RELATED APPLICATIONS

This application is a continuation of U.S. patent application Ser. No.15/488,029 filed on Apr. 14, 2017, which is a continuation of U.S.patent application Ser. No. 14/553,480, filed Nov. 25, 2014, which is acontinuation of U.S. patent application Ser. No. 12/252,803, filed Oct.16, 2008, now issued U.S. Pat. No. 8,898,278, which (i) claims priorityto U.S. Provisional Patent Application No. 60/980,663, filed Oct. 17,2007; and (ii) is also a continuation-in-part of U.S. patent applicationSer. No. 11/836,747, filed Aug. 9, 2007, now issued U.S. Pat. No.7,747,739, which claims priority to U.S. Provisional Patent ApplicationNo. 60/822,047, filed Aug. 10, 2006; U.S. Provisional Patent ApplicationNo. 60/869,439, filed Dec. 11, 2006; and U.S. Provisional PatentApplication No. 60/915,347, filed May 1, 2007.

This application is also related to U.S. patent application Ser. No.11/837,407, filed Aug. 10, 2007; U.S. patent application Ser. No.11/836,743, filed Aug. 9, 2007; U.S. patent application Ser. No.11/836,745, filed Aug. 9, 2007; U.S. patent application Ser. No.11/836,749, filed Aug. 9, 2007, now issued U.S. Pat. No. 7,844,370; U.S.patent application Ser. No. 11/836,752, filed Aug. 9, 2007; U.S. patentapplication Ser. No. 11/836,756, filed Aug. 9, 2007, now issued U.S.Pat. No. 7,949,435; U.S. patent application Ser. No. 11/836,760, filedAug. 9, 2007; U.S. patent application Ser. No. 12/252,209, filed Oct.15, 2008; and U.S. patent application Ser. No. 12/826,282, filed Jun.29, 2010. The entire contents of each of which is hereby incorporatedherein by reference.

BACKGROUND

Today's electric power and transportation systems suffer from a numberof drawbacks. Pollution, especially greenhouse gas emissions, isprevalent because approximately half of all electric power generated inthe United States is produced by burning coal. Virtually all vehicles inthe United States are powered by burning petroleum products, such asgasoline or petro-diesel. It is now widely recognized that humanconsumption of these fossil fuels is the major cause of elevated levelsof atmospheric greenhouse gases, especially carbon dioxide (CO₂), whichin turn disrupts the global climate, often with destructive sideeffects. Besides producing greenhouse gases, burning fossil fuels alsoadd substantial amounts of toxic pollutants to the atmosphere andenvironment. The transportation system, with its high dependence onfossil fuels, is especially carbon-intensive. That is, physical units ofwork performed in the transportation system typically discharge asignificantly larger amount of CO₂ into the atmosphere than the sameunits of work performed electrically.

With respect to the electric power grid, expensive peak power electricpower delivered during periods of peak demand—can cost substantiallymore than off-peak power. The electric power grid itself has becomeincreasingly unreliable and antiquated, as evidenced by frequentlarge-scale power outages. Grid instability wastes energy, both directlyand indirectly (for example, by encouraging power consumers to installinefficient forms of backup generation).

While clean forms of energy generation, such as wind and solar, can helpto address the above problems, they suffer from intermittency. Hence,grid operators are reluctant to rely heavily on these sources, making itdifficult to move away from standard, typically carbon-intensive formsof electricity.

The electric power grid contains limited inherent facility for storingelectrical energy. Electricity must be generated constantly to meetuncertain demand, which often results in over-generation (and hencewasted energy) and sometimes results in under-generation (and hencepower failures).

Distributed electric resources, in mass can, in principle, provide asignificant resource for addressing the above problems. However, currentpower services infrastructure lacks provisioning and flexibility thatare required for aggregating a large number of small-scale resources(e.g., electric vehicle batteries) to meet medium- and large-scale needsof power services.

Thus, significant opportunities for improvement exist in the electricaland transportation sectors, and in the way these sectors interact.Fuel-powered vehicles could be replaced with vehicles whose power comesentirely or substantially from electricity. Polluting forms of electricpower generation could be replaced with clean ones. Real-time balancingof generation and load can be realized with reduced cost andenvironmental impact. More economical, reliable electrical power can beprovided at times of peak demand. Power services, such as regulation andspinning reserves, can be provided to electricity markets to stabilizethe grid and provide a significant economic opportunity. Technologiescan be enabled to provide broader use of intermittent power sources,such as wind and solar.

Robust, grid-connected electrical storage could store electrical energyduring periods of over-production for redelivery to the grid duringperiods of under-supply. Electric vehicle batteries in vast numberscould participate in this grid-connected storage. However, a singlevehicle battery is insignificant when compared with the needs of thepower grid. What is needed is a way to coordinate vast numbers ofelectric vehicle batteries, as electric vehicles become more popular andprevalent.

Low-level electrical and communication interfaces to enable charging anddischarging of electric vehicles with respect to the grid is describedin U.S. Pat. No. 5,642,270 to Green et al., entitled, “Battery poweredelectric vehicle and electrical supply system,” incorporated herein byreference. The Green reference describes a bi-directional charging andcommunication system for grid-connected electric vehicles, but does notaddress the information processing requirements of dealing with large,mobile populations of electric vehicles, the complexities of billing (orcompensating) vehicle owners, nor the complexities of assembling mobilepools of electric vehicles into aggregate power resources robust enoughto support firm power service contracts with grid operators.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 is a diagram of an exemplary power aggregation system.

FIG. 2 is a diagram of exemplary connections between an electricvehicle, the power grid, and the Internet.

FIG. 3 is a block diagram of exemplary connections between an electricresource and a flow control server of the power aggregation system.

FIG. 4 is a diagram of an exemplary layout of the power aggregationsystem.

FIG. 5 is a diagram of exemplary control areas m the power aggregationsystem.

FIG. 6 is a diagram of multiple flow control centers in the poweraggregation system.

FIG. 7 is a block diagram of an exemplary flow control server.

FIG. 8 is block diagram of an exemplary remote intelligent power flowmodule.

FIG. 9 is a diagram of a first exemplary technique for locating aconnection location of an electric resource on a power grid.

FIG. 10 is a diagram of a second exemplary technique for locating aconnection location of an electric resource on the power grid.

FIG. 11 is a diagram of a third exemplary technique for locating aconnection location of an electric resource on the power grid.

FIG. 12 is a diagram of a fourth exemplary technique for locating aconnection location of an electric resource on the power grid network.

FIG. 13 is diagram of exemplary safety measures in a vehicle-to-homeimplementation of the power aggregation system.

FIG. 14 is a diagram of exemplary safety measures when multiple electricresources flow power to a home in the power aggregation system.

FIG. 15 is a block diagram of an exemplary smart disconnect of the poweraggregation system.

FIG. 16 is a flow diagram of an exemplary method of power aggregation.

FIG. 17 is a flow diagram of an exemplary method of communicativelycontrolling an electric resource for power aggregation.

FIG. 18 is a flow diagram of an exemplary method of meteringbidirectional power of an electric resource.

FIG. 19 is a flow diagram of an exemplary method of determining anelectric network location of an electric resource.

FIG. 20 is a flow diagram of an exemplary method of scheduling poweraggregation.

FIG. 21 is a flow diagram of an exemplary method of smart islanding.

FIG. 22 is a flow diagram of an exemplary method of extending a userinterface for power aggregation.

FIG. 23 is a flow diagram of an exemplary method of gaining andmaintaining electric vehicle owners in a power aggregation system.

DETAILED DESCRIPTION

Described herein is a power aggregation system for distributed electricresources, and associated methods. In one implementation, the exemplarysystem communicates over the Internet and/or some other public orprivate networks with numerous individual electric resources connectedto a power grid (hereinafter, “grid”). By communicating, the exemplarysystem can dynamically aggregate these electric resources to providepower services to grid operators (e.g. utilities. Independent SystemOperators (ISO), etc.). “Power services” as used herein, refers toenergy delivery as well as other ancillary services including demandresponse, regulation, spinning reserves, non-spinning reserves, energyimbalance, and similar products. “Aggregation” as used herein refers tothe ability to control power flows into and out of a set of spatiallydistributed electric resources with the purpose of providing a powerservice of larger magnitude. “Power grid operator” as used herein,refers to the entity that is responsible for maintaining the operationand stability of the power grid within or across an electric controlarea. The power grid operator may constitute some combination ofmanual/human action/intervention and automated processes controllinggeneration signals in response to system sensors. A “control areaoperator” is one example of a power grid operator. “Control area” asused herein, refers to a contained portion of the electrical grid withdefined input and output pons. The net flow of power into this area mustequal (within some error tolerance) the sum of the power consumptionwithin the area and power outflow from the area.

“Power grid” as used herein means a power distribution system/networkthat connects producers of power with consumers of power. The networkmay include generators, transformers, interconnects, switching stations,and safety equipment as part of cither/both the transmission system(i.e., bulk power) or the distribution system (i.e. retail power). Theexemplary power aggregation system is vertically scalable for use with aneighborhood, a city, a sector, a control area, or (for example) one ofthe eight large-scale Interconnects in the North American ElectricReliability Council (NERC). Moreover, the exemplary system ishorizontally scalable for use in providing power services to multiplegrid areas simultaneously.

“Grid conditions” as used herein, means the need for more or less powerflowing in or out of a section of the electric power grid, in a responseto one of a number of conditions, for example supply changes, demandchanges, contingencies and failures, ramping events, etc. These gridconditions typically manifest themselves as power quality events such asunder- or over-voltage events and under- or over-frequency events.

“Power quality events” as used herein typically refers to manifestationsof power grid instability including voltage deviations and frequencydeviations; additionally, power quality events as used herein alsoincludes other disturbances in the quality of the power delivered by thepower grid such as sub-cycle voltage spikes and harmonics.

“Electric resource” as used herein typically refers to electricalentities that can be commanded to do some or all of these three things:take power (act as load), provide power (act as power generation orsource), and store energy. Examples may include battery/charger/invertersystems for electric or hybrid vehicles, repositories ofused-but-serviceable electric vehicle batteries, fixed energy storage,fuel cell generators, emergency generators, controllable loads, etc.

“Electric vehicle” is used broadly herein to refer to pure electric andhybrid electric vehicles, such as plug-in hybrid electric vehicles(PHEVs), especially vehicles that have significant storage batterycapacity and that connect to the power grid for recharging the battery.More specifically, electric vehicle means a vehicle that gels some orall of its energy for motion and other purposes from the power grid.Moreover, an electric vehicle has an energy storage system, which mayconsist of batteries, capacitors, etc., or some combination thereof. Anelectric vehicle may or may not have the capability to provide powerback to the electric grid.

Electric vehicle “energy storage systems” (batteries, supercapacitors,and/or other energy storage devices) are used herein as a representativeexample of electric resources intermittently or permanently connected tothe grid that can have dynamic input and output of power. Such batteriescan function as a power source or a power load. A collection ofaggregated electric vehicle batteries can become a statistically stableresource across numerous batteries, despite recognizable tidalconnection trends (e.g., an increase in the total number of vehiclesconnected to the grid at night: a downswing in the collective number ofconnected batteries as the morning commute begins, etc.) Across vastnumbers of electric vehicle batteries, connection trends are predictableand such batteries become a stable and reliable resource to call upon,should the grid or a part of the grid (such as a person's home in ablackout) experience a need for increased or decreased power. Datacollection and storage also enable the power aggregation system topredict connection behavior on a per-user basis.

Exemplary System

FIG. 1 shows an exemplary power aggregation system 100. A flow controlcenter 102 is communicatively coupled with a network, such as apublic/private mix that includes the Internet 104, and includes one ormore servers 106 providing a centralized power aggregation service.“Internet” 104 will be used herein as representative of many differenttypes of communicative networks and network mixtures. Via a network,such as the Internet 104, the flow control center 102 maintainscommunication 108 with operators of power grid(s), and communication 110with remote resources, i.e., communication with peripheral electricresources 112 (“end” or “terminal” nodes devices of a power network)that are connected to the power grid 114. In one implementation,powerline communicators (PLCs), such as those that include or consist ofEthernet-over-powerline bridges 120 are implemented at connectionlocations so that the “last mile” (in this case, last feet—e.g., in aresidence 124) of Internet communication with remote resources isimplemented over the same wire that connects each electric resource 112to the power grid 114. Thus, each physical location of each electricresource 112 may be associated with a correspondingEthernet-over-powerline bridge 120 (hereinafter, “bridge”) at or nearthe same location as the electric resource 112. Each bridge 120 istypically connected to an Internet access point of a location owner, aswill be described in greater detail below. The communication medium fromflow control center 102 to the connection location, such as residence124, can take many forms, such as cable modem, DSL, satellite, fiber,WiMax, etc. In a variation, electric resources 112 may connect with theInternet by a different medium than the same power wire that connectsthem to the power grid 114. For example, a given electric resource 112may have its own wireless capability to connect directly with theInternet 104 and thereby with the flow control center 102.

Electric resources 112 of the exemplary power aggregation system 100 mayinclude the batteries of electric vehicles connected to the power grid114 at residences 124, parking lots 126 etc.; batteries in a repository128, fuel cell generators, private dams, conventional power plants, andother resources that produce electricity and/or store electricityphysically or electrically.

In one implementation, each participating electric resource 112 or groupof local resources has a corresponding remote intelligent power flow(IPF) module 134 (hereinafter, “remote IPF module” 134). The centralizedflow control center 102 administers the power aggregation system 100 bycommunicating with the remote IPF modules 134 distributed peripherallyamong the electric resources 112. The remote IPF modules 134 performseveral different functions, including providing the flow control center102 with the statuses of remote resources; conn-oiling the amount,direction, and timing of power being transferred into or out of a remoteelectric resource 112; provide metering of power being transferred intoor out of a remote electric resource 112; providing safety measuresduring power transfer and changes of conditions in the power grid 114;logging activities; and providing self-contained control of powertransfer and safety measures when communication with the flow controlcenter 102 is interrupted. The remote IPF modules 134 will be describedin greater detail below.

FIG. 2 shows another view of exemplary electrical and communicativeconnections to an electric resource 112. In this example, an electricvehicle 200 includes a battery bank 202 and an exemplary remote IPFmodule 134. The electric vehicle 200 may conned to a conventional wallreceptacle (wall cutlet) 204 of a residence 124, the wall receptacle 204representing the peripheral edge of the power grid 114 connected via aresidential powerline 206.

In one implementation, the power cord 208 between the electric vehicle200 and the wall outlet 204 can be composed of only conventional wireand insulation for conducting alternating current (AC) power to and fromthe electric vehicle 200. In FIG. 2, a location-specific connectionlocality module 210 performs the function of network access point-inthis case, the Internet access point. A bridge 120 intervenes betweenthe receptacle 204 and the network access point so that the power cord208 can also carry network communications between the electric vehicle200 and the receptacle 204. With such a bridge 120 and connectionlocality module 210 in place in a connection location, no other specialwiring or physical medium is needed to communicate with the remote IPFmodule 134 of the electric vehicle 200 other than a conventional powercord 208 for providing residential line current at conventional voltage.Upstream of the connection locality module 210, power and communicationwith the electric vehicle 200 are resolved into the powerline 206 and anInternet cable 104.

Alternatively, the power cord 208 may include safety features not foundin conventional power and extension cords. For example, an electricalplug 212 of the power cord 208 may include electrical and/or mechanicalsafeguard components to prevent the remote IPF module 134 fromelectrifying or exposing the male conductors of the power cord 208 whenthe conductors are exposed to a human user.

FIG. 3 shows another implementation of the connection locality module210 of FIG. 2, in greater detail. In FIG. 3, an electric resource 112has an associated remote IPF module 134, including a bridge 120. Thepower cord 208 connects the electric resource 112 to the power grid 114and also to the connection locality module 210 in order to communicatewith the flow control server 106.

The connection locality module 210 includes another instance of a bridge120′, connected to a network access point 302, which may include suchcomponents as a router, switch, and/or modem, to establish a hardwiredor wireless connection with, in this case, the Internet 104. In oneimplementation, the power cord 208 between the two bridges 120 and 120′is replaced by a wireless Internet link, such as a wireless transceiverin the remote IPF module 134 and a wireless router in the connectionlocality module 210.

FIG. 4 shows an exemplary layout 400 of the power aggregation system100. The flow control center 102 can be connected to many differententities, e.g., via the Internet 104, for communicating and receivinginformation. The exemplary layout 400 includes electric resources 112,such as plug-in electric vehicles 200, physically connected to the gridwithin a single control area 402. The electric resources 112 become anenergy resource for grid operators 404 to utilize.

The exemplary layout 400 also includes end users 406 classified intoelectric resource owners 408 and electrical connection location owners410, who may or may not be one and the same. In fact, the stakeholdersin an exemplary power aggregation system 100 include the system operatorat the flow control center 102, the grid operator 404, the resourceowner 408, and the owner of the location 410 at which the electricresource 112 is connected to the power grid 114.

Electrical connection location owners 410 can include:

-   -   Rental car lots—rental car companies often have a large portion        of their fleet parked in the lot. They can purchase fleets of        electric vehicles 200 and participating in a power aggregation        system 100, generate revenue from idle fleet vehicles.    -   Public parking lots—parking lot owners can participate in the        power aggregation system 100 to generate revenue from parked        electric vehicles 200. Vehicle owners can be offered free        parking, or additional incentives, in exchange for providing        power services.    -   Workplace parking—employers can participate in a power        aggregation system 100 to generate revenue from parked employee        electric vehicles 200. Employees can be offered incentives in        exchange for providing power services.    -   Residences—a home garage can merely be equipped with a        connection locality module 210 to enable the homeowner to        participate in the power aggregation system 100 and generate        revenue from a parked car. Also, the vehicle battery 202 and        associated power electronics within, the vehicle can provide        local power backup power during times of peak load or power        outages.    -   Residential neighborhoods—neighborhoods can participate in a        power aggregation system 100 and be equipped with power-delivery        devices (deployed, for example, by homeowner cooperative groups)        that generate revenue from parked electric vehicles 200.    -   The grid operations 116 of FIG. 4 collectively include        interactions with energy markets 412, the interactions of grid        operators 404, and the interactions of automated grid        controllers 118 that perform automatic physical control of the        power grid 114.

The flow control center 102 may also be coupled with information sources414 for input of weather reports, events, price feeds, etc. Other datasources 414 include the system stakeholders, public databases, andhistorical system data, which may be used to optimize system performanceand to satisfy constraints on the exemplary power aggregation system100.

Thus, an exemplary power aggregation system 100 may consist ofcomponents that:

-   -   communicate with the electric resources 112 to gather data and        actuate charging discharging of the electric resources 112;    -   gather real-time energy prices;    -   gather real-time resource statistics;    -   predict behavior of electric resources 112 (connectedness,        location, state (such as battery State-Of-Charge) at time of        connect disconnect);    -   predict behavior of the power grid 114/load;    -   encrypt communications for privacy and data security;    -   Actuate charging of electric vehicles 200 to optimize some        figure(s) of merit; offer guidelines or guarantees about load        availability for various points in the future, etc.

These components can be running on a single computing resource(computer, etc.), or on a distributed set of resources (eitherphysically co-located or not).

Exemplary IPF systems 100 in such a layout 400 can provide manybenefits: for example, lower-cost ancillary services (i.e., powerservices), fine-grained (both temporally and spatially) control overresource scheduling, guaranteed reliability and service levels,increased service levels via intelligent resource scheduling, firming ofintermittent generation sources such as wind and solar power generation.

The exemplary power aggregation system 100 enables a grid operator 404to control the aggregated electric resources 112 connected to the powergrid 114. An electric resource 112 can act as a power source, load, orstorage, and the resource 112 may exhibit combinations of theseproperties. Control of an electric resource 112 is the ability toactuate power consumption, generation, or energy storage from anaggregate of these electric resources 112.

FIG. 5 shows the rote of multiple control areas 402 in the exemplarypower aggregation system 100. Each electric resource 112 can beconnected to the power aggregation system 100 within a specificelectrical control area. A single instance of the flow control center102 can administer electric resources 112 from multiple distinct controlareas 501 (e.g., control areas 502, 504, and 506). In oneimplementation, this functionality is achieved by logically partitioningresources within the power aggregation system 100. For example, when thecontrol areas 402 include an arbitrary number of control areas, controlarea “A” 502, control area “B” 504, . . . , control area “n” 506, thengrid operations 116 can include corresponding control area operators508, 510, . . . , and 512. Further division into a control hierarchythat includes control division groupings above and below the illustratedcontrol areas 402 allows the power aggregation system 100 to scale topower grids 114 of different magnitudes and/or to varying numbers ofelectric resources 112 connected with a power grid 114.

FIG. 6 shows an exemplary layout 600 of an exemplary power aggregationsystem 100 that uses multiple centralized flow control centers 102 and102′. Each flow control center 102 and 102′ has its own respective endusers 406 and 406′. Control areas 402 to be administered by eachspecific instance of a flow control center 102 can be assigneddynamically. For example, a first flow control center 102 may administercontrol area A 502 and control area B 504, while a second flow controlcenter 102′ administers control area n 506. Likewise, correspondingcontrol area operators (508, 510, and 512) are served by the same flowcontrol center 102 that serves their respective different control areas.

Exemplary Flow Control Server

FIG. 7 shows an exemplary server 106 of the flow control center 102. Theillustrated implementation in FIG. 7 is only one example configuration,for descriptive purposes. Many other arrangements of the illustratedcomponents or even different components constituting an exemplary server106 of the flow control center 102 are possible within the scope of thesubject matter. Such an exemplary server 106 and flow control center 102can be executed in hardware, software, or combinations of hardware,software, firmware, etc.

The exemplary flow control server 106 includes a connection manager 702to communicate with electric resources 112, a prediction engine 704 thatmay include a learning engine 706 and a statistics engine 708, aconstraint optimizer 710, and a grid interaction manager 712 to receivegrid control signals 714. Grid control signals 714 are sometimesreferred to as generation control signals, such as automated generationcontrol (AGC) signals. The flow control server 106 may further include adatabase/in formation warehouse 716, a web server 718 to present a userinterface to electric resource owners 408, grid operators 404, andelectrical connection location owners 410; a contract manager 720 tonegotiate contract terms with energy markets 412, and an informationacquisition engine 414 to track weather, relevant news events, etc., anddownload information from public and private databases 722 forpredicting behavior of large groups of the electric resources 112,monitoring energy prices, negotiating contracts, etc.

Operation of an Exemplary Flow Control Server

The connection manager 702 maintains a communications channel with eachelectric resource 112 that is connected to the power aggregation system100. That is, the connection manager 702 allows each electric resource112 to log on and communicate, e.g., using Internet Protocol (IP) if thenetwork is the Internet 104. In other words, the electric resources 112call home. That is, in one implementation they always initiate theconnection with the server 106. This facet enables the exemplary IPFmodules 134 to work around problems with firewalls, IP addressing,reliability, etc.

For example, when an electric resource 112, such as an electric vehicle200 plugs in at home 124, the IPF module 134 can connect to the home'srouter via the powerline connection. The router will assign the vehicle200 an address (DHCP), and the vehicle 200 can connect to the server 106(no holes in the firewall needed from this direction).

If the connection is terminated for any reason (including the serverinstance dies), then the IPF module 134 knows to call home again andconnect to the next available server resource.

The grid interaction manager 712 receives and interprets signals fromthe interface of the automated grid controller 118 of a grid operator404. In one implementation, the grid interaction manager 712 alsogenerates signals to send to automated grid controllers 118. The scopeof the signals to be sent depends on agreements or contracts betweengrid operators 404 and the exemplary power aggregation system 100. Inone scenario the grid interaction manager 712 sends information aboutthe availability of aggregate electric resources 112 to receive powerfrom the grid 114 or supply power to the grid 114. In another variation,a contract may allow the grid interaction manager 712 to send controlsignals to the automated grid controller 118—to control the grid 114,subject to the built-in constraints of the automated grid controller 118and subject to the scope of control allowed by the contract.

The database 716 can store all of the data relevant to the poweraggregation system 100 including electric resource logs, e.g., forelectric vehicles 200, electrical connection information, per-vehicleenergy metering data, resource owner preferences, account information,etc.

The web server 718 provides a user interface to the system stakeholders,as described above. Such a user interface serves primarily as amechanism for conveying information to the users, but in some cases, theuser interface serves to acquire data, such as preferences, from theusers. In one implementation, the web server 718 can also initiatecontact with participating electric resource owners 408 to advertiseoffers for exchanging electrical power.

The bidding/contract manager 720 interacts with the grid operators 404and their associated energy markets 412 to determine systemavailability, pricing, service levels, etc.

The information acquisition engine 414 communicates with public andprivate databases 722, as mentioned above, to gather data that isrelevant to the operation of the power aggregation system 100.

The prediction engine 704 may use data from the data warehouse 716 tomake predictions about electric resource behavior, such as when electricresources 112 will connect and disconnect, global electric resourceavailability, electrical system load, real-time energy prices, etc. Thepredictions enable the power aggregation system 100 to utilize morefully the electric resources 112 connected to the power grid 114. Thelearning engine 706 may track, record, and process actual electricresource behavior, e.g., by learning behavior of a sample orcross-section of a large population of electric resources 112. Thestatistics engine 708 may apply various probabilistic techniques to theresource behavior to note trends and make predictions.

In one implementation, the prediction engine 704 performs predictionsvia collaborative filtering. The prediction engine 704 can also performper-user predictions of one or more parameters, including, for example,connect-time, connect duration, state-of-charge at connect time, andconnection location. In order to perform per-user prediction, theprediction engine 704 may draw upon information, such as historicaldata, connect time (day of week, week of month, month of year, holidays,etc.), state-of-charge at connect, connection location, etc. In oneimplementation, a time series prediction can be computed via a recurrentneural network, a dynamic Bayesian network, or other directed graphicalmodel.

In one scenario, for one user disconnected from the grid 314, theprediction engine 704 can predict the time of the next connection, thestate-of-charge at connection time, the location of the connection (andmay assign it a probability/likelihood). Once the resource 112 hasconnected, the time-of-connection, state-of-charge at-connection, andconnection location become further inputs to refinements of thepredictions of the connection duration. These predictions help to guidepredictions of total system availability as well as to determine a moreaccurate cost function for resource allocation.

Building a parameterized prediction model for each unique user is notalways scalable in time or space. Therefore, in one implementation,rather than use one model for each user in the system 100, theprediction engine 704 builds a reduced set of models where each model inthe reduced set is used to predict the behavior of many users. To decidehow to group similar users for model creation and assignment, the system100 can identify features of each user, such as number of uniqueconnections/disconnections per day, typical connection time(s), averageconnection duration, average state-of-charge at connection time, etc.,and can create clusters of users in either a full feature space or insome reduced feature space that is computed via a dimensionalityreduction algorithm such as Principal Components Analysis, RandomProjection, etc. Once the prediction engine 704 has assigned users to acluster, the collective data from all of the users in that cluster isused to create a predictive model that will be used for the predictionsof each user in the cluster. In one implementation, the clusterassignment procedure is varied to optimize the system 100 for speed(less clusters), for accuracy (more clusters), or some combination ofthe two.

This exemplary clustering technique has multiple benefits. First, itenables a reduced set of models, and therefore reduced model parameters,which reduces the computation time for making predictions. It alsoreduces the storage space of the model parameters. Second, byidentifying traits (or features) of new users to the system 100, thesenew users can be assigned to an existing cluster of users with similartraits, and the cluster model, built from the extensive data of theexisting users, can make more accurate predictions about the new usermore quickly because it is leveraging the historical performance ofsimilar users. Of course, over time, individual users may change theirbehaviors and may be reassigned to new clusters that fit their behaviorbetter.

The constraint optimizer 710 combines information from the predictionengine 704, the data warehouse 716, and the contract manager 720 togenerate resource control signals that will satisfy the systemconstraints. For example, the constraint optimizer 710 can signal anelectric vehicle 200 to charge its battery bank 202 at a certaincharging rate and later to discharge the battery bank 202 for uploadingpower to the power grid 114 at a certain upload rate; the power transferrates and the timing schedules of the power transfers optimized to fitthe tracked individual connect and disconnect behavior of the particularelectric vehicle 200 and also optimized to fit a daily power supply anddemand “breathing cycle” of the power grid 114.

In one implementation, the constraint optimizer 710 plays a key role inconverting generation control signals 714 into vehicle control signals,mediated by the connection manager 702. Mapping generation controlsignals 714 from a grid operator 404 into control signals that are sentto each unique electrical resource 112 in the system 100 is an exampleof a specific constraint optimization problem.

Each resource 112 has associated constraints, either hard or soft.Examples of resource constraints may include: price sensitivity of theowner, vehicle state-of-charge (e.g., if the vehicle 200 is fullycharged, it cannot participate in loading the grid 114), predictedamount of time until the resource 112 disconnects from the system 100,owner sensitivity to revenue versus state-of-charge, electrical limitsof the resource 114, manual charging overrides by resource owners 408,etc. The constraints on a particular resource 112 can be used to assigna cost for activating each of the resource's particular actions. Forexample, a resource whose storage system 202 has little energy stored init will have a low cost associated with the charging operation, but avery high cost for the generation operation. A fully charged resource112 that is predicted to be available for ten hours will have a lowercost generation operation than a fully charged resource 112 that ispredicted to be disconnected within the next 15 minutes, representingthe negative consequence of delivering a less-than-full resource to itsowner.

The following is one example scenario of convening one generating signal714 that comprises a system operating level (e.g. −10 megawatts to +10megawatts, where + represents load, − represents generation) to avehicle control signal. It is worth noting that because the system 100can meter the actual power flows in each resource 112, the actual systemoperating level is known at all times.

In this example, assume the initial system operating level is 0megawatts, no resources are active (taking or delivering power from thegrid), and the negotiated aggregation service contract level for thenext hour is +/−5 megawatts.

In this implementation, the exemplary power aggregation system 100maintains three lists of available resources 112. The first listcontains resources 112 that can be activated for charging (load) inpriority order. There is a second list of the resources 112 ordered bypriority for discharging (generation). Each of the resources 112 inthese lists (e.g., all resources 112 can have a position in both lists)have an associated cost. The priority order of the lists is directlyrelated to the cost (i.e., the lists are soiled from lowest cost tohighest cost). Assigning cost values to each resource 112 is importantbecause it enables the comparison of two operations that achieve similarresults with respect to system operation. For example, adding one unitof charging (load, taking power from the grid) to the system isequivalent to removing one unit of generation. To perform any operationthat increases or decreases the system output, there may be multipleaction choices and in one implementation the system 100 selects thelowest cost operation. The third list of resources 112 containsresources with hard constraints. For example, resources whose owner's408 have overridden the system 100 to force charging will be placed onthe third list of static resources.

At time “1,” the grid-operator-requested operating level changes to +2megawatts. The system activates charging the first ‘n’ resources fromthe list, where ‘n’ is the number of resources whose additive load ispredicted to equal 2 megawatts. After the resources are activated, theresult of the activations are monitored to determine the actual resultof the action. If more than 2 megawatts of load is active, the systemwill disable charging in reverse priority order to maintain systemoperation within the error tolerance specified by the contract.

From time “1” until time “2,” the requested operating level remainsconstant at 2 megawatts. However, the behavior of some of the electricalresources may not be static. For example, some vehicles 200 that arepart of the 2 megawatts system operation may become full(state-of-charge=100%) or may disconnect from the system 100. Othervehicles 200 may connect to the system 100 and demand immediatecharging. All of these actions will cause a change in the operatinglevel of the power aggregation system 100. Therefore, the system 100continuously monitors the system operating level and activates ordeactivates resources 112 to maintain the operating level within theerror tolerance specified by the contract.

At time “2,” the grid-operator-requested operating level decreases to −1megawatts. The system consults the lists of available resources andchooses the lowest cost set of resources to achieve a system operatinglevel of −1 megawatts. Specifically, the system moves sequentiallythrough the priority lists, comparing the cost of enabling generationversus disabling charging, and activating the lowest cost resource ateach time step. Once the operating level reaches −1 megawatts, thesystem 100 continues to monitor the actual operating level, looking fordeviations that would require the activation of an additional resource112 to maintain the operating level within the error tolerance specifiedby the contract.

In one implementation, an exemplary costing mechanism is fed informationon the real-time grid generation mix to determine the marginalconsequences of charging or generation (vehicle 200 to grid 114) on a“carbon footprint,” the impact on fossil fuel resources and theenvironment in general. The exemplary system 100 also enables optimizingfor any cost metric, or a weighted combination of several. The system100 can optimize figures of merit that may include, for example, acombination of maximizing economic value and minimizing environmentalimpact, etc.

In one implementation, the system 100 also uses cost as a temporalvariable. For example, if the system 100 schedules a discharged pack tocharge during an upcoming time window, the system 100 can predict itslook-ahead cost profile as it charges, allowing the system 100 tofurther optimize, adaptively. That is, in some circumstances the system100 knows that it will have a high-capacity generation resource by acertain future time.

Multiple components of the flow control server 106 constitute ascheduling system that has multiple functions and components:

-   -   data collection (gathers real-time data and stores historical        data);    -   projections via the prediction engine 704, which inputs        real-time data, historical data, etc.; and outputs resource        availability forecasts;    -   optimizations built on resource availability forecasts,        constraints, such as command signals from grid operators 404,        user preferences, weather conditions, etc. The optimizations can        take the form of resource control plans that optimize a desired        metric.

The scheduling function can enable a number of useful energy services,including:

-   -   ancillary services, such as rapid response services and fast        regulation;    -   energy to compensate for sudden, foreseeable, or unexpected grid        imbalances;    -   response to routine and unstable demands;    -   firming of renewable energy sources (e.g. complementing        wind-generated power).

An exemplary power aggregation system 100 aggregates and controls theload presented by many charging/uploading electric vehicles 200 toprovide power services (ancillary energy services) such as regulationand spinning reserves. Thus, it is possible to meet call timerequirements of grid operators 404 by summing multiple electricresources 112. For example, twelve operating loads of 5 kW each can bedisabled to provide 60 kW of spinning reserves for one hour. However, ifeach load can be disabled for at most 30 minutes and the minimum calltime is two hours, the loads can be disabled in series (three at a time)to provide 15 kW of reserves for two hours. Of course, more complexinterleavings of individual electric resources by the power aggregationsystem 100 are possible.

For a utility (or electrical power distribution entity) to maximizedistribution efficiency, the utility needs to minimize reactive powerflows. Typically, there are a number of methods used to minimizereactive power flows including switching inductor or capacitor banksinto the distribution system to modify the power factor in differentparts of the system. To manage and control this dynamic Volt-AmperesReactive (VAR) support effectively, it must be done in a location-awaremanner. In one implementation, the power aggregation system 100 includespower-factor correction circuitry placed in electric vehicles 200 withthe exemplary remote IPF module 134, thus enabling such a service.Specifically, the electric vehicles 200 can have capacitors (orinductors) that can be dynamically connected to the grid, independent ofwhether the electric vehicle 200 is charging, delivering power, or doingnothing. This service can then be sold to utilities for distributionlevel dynamic VAR support. The power aggregation system 100 can bothsense the need for VAR support in a distributed manner and use thedistributed remote IPF modules 134 to take actions that provide VARsupport without grid operator 404 intervention.

Exemplary Remote IPF Module

FIG. 8 shows the remote IPF module 134 of FIGS. 1 and 2 in greaterdetail. The illustrated remote IPF module 134 is only one exampleconfiguration, for descriptive purposes. Many other arrangements of theillustrated components or even different components constituting anexemplary remote IPF module 134 are possible within the scope of thesubject matter. Such an exemplary remote IPF module 134 has somehardware components and some components that can be executed inhardware, software, or combinations of hardware, software, firmware,etc.

The illustrated example of a remote IPF module 134 is represented by animplementation suited for an electric vehicle 200. Thus, some vehiclesystems 800 are included as part of the exemplary remote IPF module 134for the sake of description. However, in other implementations, theremote IPF module 134 may exclude some or all of the vehicles systems800 from being counted as components of the remote IPF module 134.

The depicted vehicle systems 800 include a vehicle computer and datainterface 802, an energy storage system, such as a battery bank 202, andan inverter/charger 804. Besides vehicle systems 800, the remote IPFmodule 134 also includes a communicative power flow controller 806. Thecommunicative power flow controller 806 in turn includes some componentsthat interface with AC power from the grid 114, such as a powerlinecommunicator, for example an Ethernet-over-powerline bridge 120, and acurrent or current/voltage (power) sensor 808, such as a current sensingtransformer.

The communicative power flow controller 806 also includes Ethernet andinformation processing components, such as a processor 810 ormicrocontroller and an associated Ethernet media access control (MAC)address 812; volatile random access memory 814, nonvolatile memory 816or data storage, an interface such as an RS-232 interface 818 or aCANbus interface 820; an Ethernet physical layer interface 822, whichenables wiring and signaling according to Ethernet standards for thephysical layer through means of network access at the MAC/Data LinkLayer and a common addressing format. The Ethernet physical layerinterface 822 provides electrical, mechanical, and procedural interfaceto the transmission medium—i.e., in one implementation, using theEthernet-over-powerline bridge 120. In a variation, wireless or othercommunication channels with the Internet 104 are used in place of theEthernet-over-powerline bridge 120.

The communicative power flow controller 806 also includes abidirectional power flow meter 824 that tracks power transfer to andfrom each electric resource 112, in this case the battery bank 202 of anelectric vehicle 200.

The communicative power flow controller 806 operates either within, orconnected to an electric vehicle 200 or other electric resource 112 toenable the aggregation of electric resources 112 introduced above (e.g.,via a wired or wireless communication interface). These above-listedcomponents may vary among different implementations of the communicativepower flow controller 806, but implementations typically include:

-   -   an intra-vehicle communications mechanism that enables        communication with other vehicle components;    -   a mechanism to communicate with the flow control center 102;    -   a processing element;    -   a data storage element;    -   a power meter; and    -   optionally, a user interface.

Implementations of the communicative power flow controller 806 canenable functionality including:

-   -   executing pre-programmed or learned behaviors when the electric        resource 112 is offline (not connected to Internet 104, or        service is unavailable);    -   storing locally-cached behavior profiles for “roaming”        connectivity (what to do when charging on a foreign system or in        disconnected operation, i.e., when there is no network        connectivity);    -   allowing the user to override current system behavior; and    -   metering power-flow information and caching meter data during        offline operation for later transaction.

Thus, the communicative power flow controller 806 includes a centralprocessor 810, interfaces 818 and 820 for communication within theelectric vehicle 200, a powerline communicator, such as anEthernet-over-powerline bridge 120 for communication external to theelectric vehicle 200, and a power flow meter 824 for measuring energyflow to and from the electric vehicle 200 via a connected AC powerline208.

Operation of the Exemplary Remote IPF Module

Continuing with electric vehicles 200 as representative of electricresources 112, during periods when such an electric vehicle 200 isparked and connected to the grid 114, the remote IPF module 134initiates a connection to the flow control server 106, registers itself,and waits for signals from the flow control server 106 that direct theremote IPF module 134 to adjust the flow of power into or out of theelectric vehicle 200. These signals are communicated to the vehiclecomputer 802 via the data interface, which may be any suitable interfaceincluding the RS-232 interface 818 or the CANbus interlace 820. Thevehicle computer 802, following the signals received from the flowcontrol server 106, controls the inverter/charger 804 to charge thevehicle's battery bank 202 or to discharge the battery bank 202 inupload to the grid 114.

Periodically, the remote IPF module 134 transmits information regardingenergy flows to the flow control server 106. If, when the electricvehicle 200 is connected to the grid 114, there is no communicationspath to the flow control server 106 (i.e., the location is not equippedproperly, or there is a network failure), the electric vehicle 200 canfollow a preprogrammed or learned behavior of off-line operation, e.g.,stored as a set of instructions in the nonvolatile memory 816. In such acase, energy transactions can also be cached in nonvolatile memory 816for later transmission to the flow control server 106.

During periods when the electric vehicle 200 is m operation astransportation, the remote IPF module 134 listens passively, loggingselect vehicle operation data for later analysis and consumption. Theremote IPF module 134 can transmit this data to the flow control server106 when a communications channel becomes available.

Exemplary Power Flow Meter

Power is the rate of energy consumption per interval of time. Powerindicates the quantify of energy transferred during a certain period oftime, thus the units of power are quantities of energy per unit of time.The exemplary power flow meter 824 measures power for a given electricresource 112 across a bi-directional flow—e.g., power from grid 114 toelectric vehicle 200 or from electric vehicle 200 to the grid 114. Inone implementation, the remote IPF module 134 can locally cache readingsfrom the power flow meter 824 to ensure accurate transactions with thecentral flow control server 106, even if the connection to the server isdown temporarily, or if the server itself is unavailable.

The exemplary power flow meter 824, in conjunction with the othercomponents of the remote IPF module 134 enables system-wide features inthe exemplary power aggregation system 100 that include:

-   -   tracking energy usage on an electric resource-specific basis;    -   power-quality monitoring (checking if voltage, frequency, etc.        deviate from their nominal operating points, and if so,        notifying grid operators, and potentially modifying resource        power flows to help correct the problem);    -   vehicle-specific billing and transactions for energy usage;    -   mobile billing (support for accurate billing when the electric        resource owner 408 is not the electrical connection location        owner 410 (i.e., not the meter account owner). Data from the        power flow meter 824 can be captured at the electric vehicle 200        for billing;    -   integration with a smart meter at the charging location        (bi-directional information exchange); and    -   tamper resistance (e.g., when the power flow meter 824 is        protected within an electric resource 112 such as an electric        vehicle 200).        Mobile Resource Locator

The exemplary power aggregation system 100 also includes varioustechniques for determining the electrical network location of a mobileelectric resource 112, such as a plug-in electric vehicle 200. Electricvehicles 200 can connect to the grid 314 in numerous locations andaccurate control and transaction of energy exchange can be enabled byspecific knowledge of the charging location.

Some of the exemplary techniques for determining electric vehiclecharging locations include:

-   -   querying a unique identifier for the location (via wired,        wireless, etc.), which can be:    -   the unique ID of the network hardware at the charging site;    -   the unique ID of the locally installed smart meter, by        communicating with the meter;    -   a unique ID installed specifically for this purpose at a site;        and    -   using GPS or other signal sources (cell, WiMAX, etc.) to        establish a “soft” (estimated geographic) location, which is        then refined based on user preferences and historical data        (e.g., vehicles tend to be plugged-in at the owner's residence        124, not a neighbor's residence).

FIG. 9 shows an exemplary technique for resolving the physical locationon the grid 114 of an electric resource 112 that is connected to theexemplary power aggregation system 100. In one implementation, theremote IPF module 134 obtains the Media Access Control (MAC) address 902of the locally installed network modem or router (Internet access point)302. The remote IPF module 134 then transmits this unique MAC identifierto the flow control server 106, which uses the identifier to resolve thelocation of the electric vehicle 200.

To discern its physical location, the remote IPF module 134 can alsosometimes use the MAC addresses or other unique identifiers of otherphysically installed nearby equipment that can communicate with theremote IPF module 134, including a “smart” utility meter 904, a cable TVbox 906, an RFID-based unit 908, or an exemplary ID unit 910 that isable to communicate with the remote IPF module 134. The ID unit 910 isdescribed in more detail in FIG. 10. MAC addresses 902 do not alwaysgive information about the physical location of the associated piece ofhardware, but in one implementation the How control server 106 includesa tracking database 912 that relates MAC addresses or other identifierswith an associated physical location of the hardware. In this manner, aremote IPF module 134 and the flow control server 106 can find a mobileelectric resource 112 wherever it connects to the power grid 114.

FIG. 10 shows another exemplary technique for determining a physicallocation of a mobile electric resource 112 on the power grid 114. Anexemplary ID unit 910 can be plugged into the grid 114 at or near acharging location. The operation of the ID unit 910 is as follows. Anewly-connected electric resource 112 searches for locally connectedresources by broadcasting a ping or message in the wireless receptionarea. In one implementation, the ID unit 910 responds 1002 to the pingand conveys a unique identifier 1004 of the ID unit 910 back to theelectric resource 112. The remote IPF module 134 of the electricresource 112 then transmits the unique identifier 1004 to theflow-control server 106, which determines the location of the ID unit910 and by proxy, the exact or the approximate network location of theelectric resource 112, depending on the size of the catchment area ofthe ID unit 910.

In another implementation, the newly-connected electric resource 112searches for locally connected resources by broadcasting a ping ormessage that includes the unique identifier 1006 of the electricresource 112. In this implementation, the ID unit 910 does not need totrust or reuse the wireless connection, and does not respond back to theremote IPF module 134 of the mobile electric resource 112, but responds1008 directly to the flow control server 106 with a message thatcontains its own unique identifier 1004 and the unique identifier 1006of the electric resource 112 that was received in the ping message. Thecentral flow control server 106 then associates the unique identifier1006 of the mobile electric resource 112 with a “connected” status anduses the other unique identifier 1004 of the ID unit 910 to determine orapproximate the physical location of the electric resource 112. Thephysical location does not have to be approximate, if a particular IDunit 910 is associated with only one exact network location. The remoteIPF module 134 learns that the ping is successful when it hears backfrom the flow control center 106 with confirmation.

Such an exemplary ID unit 910 is particularly useful in situations inwhich the communications path between the electric resource 112 and theflow control server 106 is via a wireless connection that does notitself enable exact determination of network location.

FIG. 11 shows another exemplary method 1100 and system 1102 fordetermining the location of a mobile electric resource 112 on the powergrid 114. In a scenario in which the electric resource 112 and the flowcontrol server 106 conduct communications via a wireless signalingscheme, it is still desirable to determine the physical connectionlocation during periods of connectedness with the grid 114.

Wireless networks (e.g., GSM, 802.11, WiMax) comprise many cells ortowers that each transmit unique identifiers. Additionally, the strengthof the connection between a tower and mobile clients connecting to thetower is a function of the client's proximity to the tower. When anelectric vehicle 200 is connected to the grid 114, the remote IPF module134 can acquire the unique identifiers of the available towers andrelate these to the signal strength of each connection, as shown indatabase 1104. The remote IPF module 134 of the electric resource 112transmits this information to the flow control server 106, where theinformation is combined with survey data, such as database 1106 so thata position inference engine 1108 can triangulate or otherwise infer thephysical location of the connected electric vehicle 200. In anotherenablement, the IPF module 134 can use the signal strength readings toresolve the resource location directly, in which case the IPF module 134transmits the location information instead of the signal strengthinformation.

Thus, the exemplary method 1100 includes acquiring (1110) the signalstrength information; communicating (1112) the acquired signal strengthinformation to the flow control server 106; and inferring (1114) thephysical location using stored tower location information and theacquired signals from the electric resource 112.

FIG. 12 shows a method 1200 and system 1202 for using signals from aglobal positioning satellite (GPS) system to determine a physicallocation of a mobile electric resource 112 on the power grid 114. UsingGPS enables a remote IPF module 134 to resolve its physical location onthe power network in a non-exact manner. This noisy location informationfrom GPS is transmitted to the flow control server 106, which uses itwith a survey information database 1204 to infer the location of theelectric resource 112.

The exemplary method 1200 includes acquiring (1206) the noisy positiondata; communicating (1208) the acquired noisy position data to the flowcontrol server 106; and inferring (1210) the location using the storedsurvey information and the acquired data.

Exemplary Transaction Methods and Business Methods

The exemplary power aggregation system 100 supports the followingfunctions and interactions:

1. Setup—The power aggregation system 100 creates contracts outside thesystem and/or bids into open markets to procure contracts for powerservices contracts via the web server 718 and contract manager 720. Thesystem 100 then resolves these requests into specific power requirementsupon dispatch from the grid operator 404, and communicates theserequirements to vehicle owners 408 by one of several communicationtechniques.

2. Delivery—The grid interaction manager 712 accepts real-time gridcontrol signals 714 from grid operators 404 through a power-deliverydevice, and responds to these signals 714 by delivering power servicesfrom connected electric vehicles 200 to the grid 114.

3. Reporting—After a power delivery event is complete, a transactionmanager can report power services transactions stored in the database716. A billing manager resolves these requests into specific credit ordebit billing transactions. These transactions may be communicated to agrid operator's or utility's billing system for account reconciliation.The transactions may also be used to make payments directly to resourceowners 408.

In one implementation, the vehicle-resident remote IPF module 134 mayinclude a communications manager to receive offers to provide powerservices, display them to the user and allow the user to respond tooffers. Sometimes this type of advertising or contracting interactioncan be carried out by the electric resource owner 408 conventionallyconnecting with the web server 718 of the flow control server 106.

In an exemplary business model of managing vehicle-based load orstorage, the exemplary power aggregation system 100 serves as anintermediary between vehicle owners 408 (individuals, fleets, etc.) andgrid operators 404 (Independent System Operators ISOs). RegionalTransmission Operators (RTOs), utilities, etc.).

The load and storage electric resource 112 presented by a single plug-inelectric vehicle 200 is not a substantial enough resource for an ISO orutility to consider controlling directly. However, by aggregating manyelectric vehicles 200 together, managing their load behavior, andexporting a simple control interface, the power aggregation system 100provides services that are valuable to grid operators 404.

Likewise, vehicle owners 408 may not be interested in participatingwithout participation being made easy, and without there being incentiveto do so. By creating value through aggregated management, the poweraggregation system 100 can provide incentives to owners in the form ofpayments, reduced charging costs, etc. The power aggregation system 100can also make the control of vehicle charging and uploading power to thegrid 114 automatic and nearly seamless to the vehicle owner 408, therebymaking participation palatable.

By placing remote IPF modules 134 in electric vehicles 200 that canmeasure attributes of power quality, the power aggregation system 100enables a massively distributed sensor network for the powerdistribution grid 114. Attributes of power quality that the poweraggregation system 100 can measure include frequency, voltage, powerfactor, harmonics, etc. Then, leveraging the communicationinfrastructure of the power aggregation system 100, including remote IPFmodules 134, this sensed data can be reported in real time to the flowcontrol server 106, where information is aggregated. Also, theinformation can be presented to the utility, or the power aggregationsystem 100 can directly correct undesirable grid conditions bycontrolling vehicle charge/power upload behavior of numerous electricvehicles 200, changing the load power factor, etc.

The exemplary power aggregation system 100 can also provideUninterruptible Power Supply (UPS) or backup power for a home/business,including interconnecting islanding circuitry. In one implementation,the power aggregation system 100 allows electric resources 112 to flowpower out of their batteries to the home (or business) to power some orall of the home's loads. Certain loads may be configured as key loads tokeep “on” during a grid power-loss event, in such a scenario, it isimportant to manage islanding of the residence 124 from the grid 114.Such a system may include anti-islanding circuitry that has the abilityto communicate with the electric vehicle 200, described further below asa smart breaker box. The ability of the remote IPF module 134 tocommunicate allows the electric vehicle 200 to know if providing poweris safe, “safe” being defined as “safe for utility line workers as aresult of the main breaker of the home being in a disconnected state.”If grid power drops, the smart breaker box disconnects from the grid andthen contacts any electric vehicles 200 or other electric resources 112participating locally, and requests them to start providing power. Whengrid power returns, the smart breaker box turns off the local powersources, and then reconnects.

For mobile billing (for when the vehicle owner 408 is different than themeter account owner 410), there are two important aspects for thebilling manager to reckon with during electric vehicle recharging: whoowns the vehicle, and who owns the meter account of the facility whererecharge is happening.

When the vehicle owner 408 is different than the meter account owner410, there are several options:

-   -   1. The meter owner 410 may give free charging.    -   2. The vehicle owner 408 may pay at the time of charging (via        credit card, account, etc.)    -   3. A pre-established account may be settled automatically.

Without oversight of the power aggregation system 100, theft of servicesmay occur. With automatic account settling, the power aggregation system100 records when electric vehicles 200 charge at locations that requirepayment, via vehicle IDs and location IDs, and via exemplary metering oftime-annotated energy flow in/out of the vehicle. In these cases, thevehicle owner 408 is billed for energy used, and that energy is notcharged to the facility's meter account owner 410 (so double-billing isavoided). A billing manager that performs automatic account settling canbe integrated with the power utility, or can be implemented as aseparate debit/credit system.

An electrical charging station, whether free or for pay, can beinstalled with a user interface that presents useful information to theuser. Specifically, by collecting information about the grid 114, thevehicle state, and the preferences of the user, the station can presentinformation such as the current electricity price, the estimatedrecharge cost, the estimated time until recharge, the estimated paymentfor uploading power to the grid 114 (either total or per hour), etc. Theinformation acquisition engine 414 communicates with the electricvehicle 20 and with public and/or private data networks 722 to acquirethe data used in calculating this information.

The exemplary power aggregation system 100 also offers other featuresfor the benefit of electric resource owners 408 (such as vehicleowners):

-   -   vehicle owners can earn free electricity for vehicle charging in        return for participating in the system;    -   vehicle owners can experience reduced charging cost by avoiding        peak time rates;    -   vehicle owners can receive payments based on the actual energy        service their vehicle provides;    -   vehicle owners can receive a preferential tariff for        participating in the system.

There are also features between the exemplary power aggregation system100 and grid operators 404;

-   -   the power aggregation system 100 as electric resource aggregator        can earn a management fee (which may be some function of        services provided), paid by the grid operator 404;    -   the power aggregation system 100 as electric resource aggregator        can sell into power markets 412;    -   grid operators 404 may pay for the power aggregation system 100,        but operate the power aggregation system 100 themselves.        Exemplary Safety and Remote Smart-Islanding

The exemplary power aggregation system 100 can include methods andcomponents for implementing safety standards and safely actuating energydischarge operations. For example, the exemplary power aggregationsystem 100 may use in-vehicle line sensors as well as smart-islandingequipment installed at particular locations. Thus, the power aggregationsystem 100 enables safe vehicle-to-grid operations. Additionally, thepower aggregation system 100 enables automatic coordination of resourcesfor backup power scenarios.

In one implementation, an electric vehicle 200 containing a remote IPFmodule 134 stops vehicle-to-grid upload of power if the remote IPFmodule 134 senses no line power originating from the grid 114. Thishalting of power upload prevents electrifying a cord that may beunplugged, or electrifying a powerline 206 that is being repaired, etc.However, this does not preclude using the electric vehicle 200 toprovide backup power if grid power is down because the safety measuresdescribed below ensure that an island condition is not created.

Additional smart-islanding equipment installed at a charging locationcan communicate with the remote IPF module 134 of an electric vehicle200 to coordinate activation of power upload to the grid 114 if gridpower drops. One particular implementation of this technology is avehicle-to-home backup power capability.

FIG. 13 shows exemplary safety measures in a vehicle-to-home scenario,in which an electric resource 112 is used to provide power to a load orset of loads (as in a home). A breaker box 1300 is connected to theutility electric meter 1302. When an electric resource 112 is flowingpower into the grid (or local loads), an islanding condition should beavoided for safety reasons. The electric resource 112 should notenergize a line that would conventionally be considered de-energized ina power outage by line workers.

A locally installed smart grid disconnect (switch) 1304 senses theutility line in order to detect a power outage condition and coordinateswith the electric resource 112 to enable vehicle-to-home power transfer.In the case of a power outage, the smart grid disconnect 1304disconnects the circuit breakers 1306 from the utility grid 114 andcommunicates with the electric resource 112 to begin power backupservices. When the utility services return to operation, the smart griddisconnect 1304 communicates with the electric resource 112 to disablethe backup services and reconnect the breakers to the utility grid 114.

FIG. 14 shows exemplary safety measures when multiple electric resources112 power a home. In this case, the smart grid disconnect 1304coordinates with all connected electric resources 112. One electricresource 112 is deemed the “master” 1400 for purposes of generating areference signal 1402 and the other resources are deemed “slaves” 1404and follow the reference of the master 1400. In a ease in which themaster 1400 disappears from the network, the smart grid disconnect 1304assigns another slave 1404 to be the reference/master 1400.

FIG. 15 shows the smart grid disconnect 1304 of FIGS. 13 and 14, ingreater detail. In one implementation, the smart grid disconnect 1304includes a processor 1502, a communicator 1504 coupled with connectedelectric resources 112, a voltages sensor 1506 capable of sensing boththe internal and utility-side AC lines, a battery 1508 for operationduring power outage conditions, and a battery charger 1510 formaintaining the charge level of the battery 1508. A controlled breakeror relay 1512 switches between grid power and electric resource-providedpower when signaled by the processor 1502.

Exemplary User Experience Options

The exemplary power aggregation system 100 can enable a number ofdesirable user features:

-   -   data collection can include distance driven and both electrical        and non-electrical fuel usage, to allow derivation and analysis        of overall vehicle efficiency (in terms of energy, expense,        environmental impact, etc.). This data is exported to the flow        control server 106 for storage 716, as well as for display on an        in-vehicle user interface, charging station user interface, and        web/cell phone user interface.    -   intelligent charging learns the vehicle behavior and adapts the        charging timing automatically. The vehicle owner 408 can        override and request immediate charging if desired.        Exemplary Methods

FIG. 16 shows an exemplary method 1600 of power aggregation. In the flowdiagram, the operation are summarized in individual blocks. Theexemplary method 1600 may be performed by hardware, software, orcombinations of hardware, software, firmware, etc., for example, bycomponents of the exemplary power aggregation system 100.

At block 1602, communication is established with each of multipleelectric resources connected to a power grid. For example, a centralflow control service can manage numerous intermittent connections withmobile electric vehicles each of which may connect to the power grid atvarious locations. An in-vehicle remote agent connects each vehicle tothe Internet when the vehicle connects to the power grid.

At block 1604, the electric resources are individually signaled toprovide power to or take power from the power grid.

FIG. 17 is a flow diagram of an exemplary method of communicativelycontrolling an electric resource for power aggregation. In the flowdiagram, the operations are summarized in individual blocks. Theexemplary method 1700 may be performed by hardware, software, orcombinations of hardware, software, firmware, etc., for example, bycomponents of the exemplary intelligent power flow (IPF) module 134.

At block 1702, communication is established between an electric resourceand a service for aggregating power.

At block 1704, information associated with the electric resource iscommunicated to the service.

At block 1706, a control signal based in part upon the information isreceived from the service.

At block 1708, the resource is controlled, e.g., to provide power to thepower grid or to take power from the grid, i.e., for storage.

At block 1710, bidirectional power flow of the electric device ismeasured, and used as part of the information associated with theelectric resource that is communicated to the service at block 1704.

FIG. 18 is a flow diagram of an exemplary method of meteringbidirectional power of an electric resource. In the flow diagram, theoperations are summarized in individual blocks. The exemplary method1800 may be performed by hardware, software, or combinations ofhardware, software, firmware, etc., for example, by components of theexemplary power flow meter 824.

At block 1802, energy transfer between an electric resource and a powergrid is measured bidirectionally.

At block 1804, the measurements are sent to a service that aggregatespower based in part on the measurements.

FIG. 19 is a flow diagram of an exemplary method of determining anelectric network location of an electric resource. In the flow diagram,the operations are summarized in individual blocks. The exemplary method1900 may be performed by hardware, software, or combinations ofhardware, software, firmware, etc., for example, by components of theexemplary power aggregation system 100.

At block 1902, physical location information is determined. The physicallocation information may be derived from such sources as GPS signals orfrom the relative strength of cell tower signals as an indicator oftheir location. Or, the physical location information may derived byreceiving a unique identifier associated with a nearby device, andfinding the location associated with that unique identifier.

At block 1904, an electric network location, e.g., of an electricresource or its connection with the power grid, is determined from thephysical location information.

FIG. 20 is a flow diagram of an exemplary method of scheduling poweraggregation. In the flow diagram, the operations are summarized inindividual blocks. The exemplary method 2000 may be performed byhardware, software, or combinations of hardware, software, firmware,etc., for example, by components of the exemplary flow control server106.

At block 2002, constraints associated with individual electric resourcesare input.

At block 2004, power aggregation is scheduled, based on the inputconstraints.

FIG. 21 is a flow diagram of an exemplary method of smart islanding. Inthe flow diagram, the operations are summarized in individual blocks.The exemplary method 2100 may be performed by hardware, software, orcombinations of hardware, software, firmware, etc., for example, bycomponents of the exemplary power aggregation system 100.

At block 2102, a power outage is sensed.

At block 2104, a local connectivity—a network isolated from the powergrid is created.

At block 2106, local energy storage resources are signaled to power thelocal connectivity.

FIG. 22 is a flow diagram of an exemplary method of extending a userinterface for power aggregation. In the flow diagram, the operations aresummarized in individual blocks. The exemplary method 2200 may beperformed by hardware, software, or combinations of hardware, software,firmware, etc., for example, by components of the exemplary poweraggregation system 100.

At block 2202, a user interface is associated with an electric resource.The user interface may displayed in, on, or near an electric resource,such as an electric vehicle that includes an energy storage system, orthe user interface may be displayed on a device associated with theowner of the electric resource, such as a cell phone or portablecomputer.

At block 2204, power aggregation preferences and constraints are inputvia the user interface. In other words, a user may control a degree ofparticipation of the electric resource in a power aggregation scenariovia the user interface. Or, the user may control the characteristics ofsuch participation.

FIG. 23 is a flow diagram of an exemplary method of gaining andmaintaining electric vehicle owners in a power aggregation system. Inthe flow diagram, the operations are summarized in individual blocks.The exemplary method 2300 may be performed by hardware, software, orcombinations of hardware, software, firmware, etc., for example, bycomponents of the exemplary power aggregation system 100.

At block 2302, electric vehicle owners are enlisted into a poweraggregation system for distributed electric resources.

At block 2304, an incentive is provided to each owner for participationin the power aggregation system.

At block 2306, recurring continued service to the power aggregationsystem is repeatedly compensated.

Although exemplary systems and methods have been described in languagespecific to structural features and/or methodological acts, it is to beunderstood that the subject matter defined in the appended claims is notnecessarily limited to the specific features or acts described. Rather,the specific features and acts are disclosed as exemplary forms ofimplementing the claimed methods, devices, systems, etc.

The invention claimed is:
 1. A method, comprising: establishing, by wayof a computer network, a communication between a mobile electricresource and a network-connected device, the mobile electric resourceincluding one or more processors including a processor to control powerflow; obtaining, with the one or more processors, a unique identifierassociated with the network-connected device; transmitting, with the oneor more processors, information regarding the mobile electric resourceto a remote server; determining, with the one or more processors or theremote server, a location of the mobile electric resource from theunique identifier; determining at least one power connection locationfrom the determined location; and charging the mobile electric resourcewith the determined at least one power connection location.
 2. Themethod of claim 1, further comprising sending the unique identifier tothe remote server.
 3. The method of claim 1, wherein the uniqueidentifier comprises a media access control (MAC) address.
 4. The methodof claim 1, wherein the network-connected device comprises one of asmart meter, a cable TV box, or a radio-frequency identification-based(RFID-based) unit.
 5. A method, comprising: establishing a communicationbetween a mobile electric resource and a transceiver device associatedwith a power connection, the mobile electric resource including one ormore processors including a processor to control power flow; obtaining,with the one or more processors, a unique identifier associated with anetwork-connected device accessible by the mobile electric resource;transmitting, with the one or more processors, information regarding themobile electric resource to a remote server; determining, with the oneor more processors or the remote server, a location of the powerconnection; and directing, with the one or more processors or the remoteserver, the power connection to charge the mobile electric resource. 6.The method of claim 5, wherein the unique identifier comprises a mediaaccess control (MAC) address.
 7. The method of claim 5, whereindirecting the power connection to charge the mobile electric resourcecomprises: automatically determining a charging plan; and charging themobile electric resource according to the charging plan.
 8. The methodof claim 7, further comprising manually overriding the charging plan. 9.The method of claim 7, further comprising: determining a status of themobile electric resource; and automatically modifying the charging planbased on the status.
 10. The method of claim 5, wherein the powerconnection is a charging station, and the method further comprises:optimizing the charging plan based on a forecasted availability of thecharging station and environmental data.
 11. The method of claim 5,wherein the mobile electric resource comprises a wireless transceiver,and the method further includes: sending, with the wireless transceiver,a signal to the transceiver device.
 12. A method, comprising:establishing, with one or more processors of a mobile electric resource,a communication between the mobile electric resource and a transceiverdevice associated with a power connection; obtaining, with the one ormore processors, a unique identifier associated with the transceiverdevice; determining, with one or more processors on the mobile electricresource, a location of the mobile electric resource based on the uniqueidentifier; transmitting, with the one or more processors, informationregarding the mobile electric resource to a remote server; and chargingthe mobile electric resource with the power connection.
 13. The methodof claim 12, further comprising: determining, with the one or moreprocessors, a location of the power connection.
 14. The method of claim13, further comprising: determining the location of the power connectionbased on the unique identifier.
 15. The method of claim 12, furthercomprising: forecasting an availability of the power connection; andautomatically determining a charging plan for the mobile electricresource based on the forecasted availability; and charging the mobileelectric resource according to the charging plan.
 16. The method ofclaim 15, further comprising: obtaining environmental data; andautomatically optimizing the charging plan based on the forecastedavailability and the environmental data.
 17. The method of claim 12,wherein the power connection includes a plurality of charging stations,and the transceiver device is associated with each of the plurality ofcharging stations.
 18. The method of claim 12, further comprisingpredicting a state-of-charge of the mobile electric resource at aconnection time with the power connection.
 19. The method of claim 12,further comprising predicting when the mobile electric resource willdisconnect from the power connection.
 20. The method of claim 12,further comprising predicting when the mobile electric resource willconnect to the power connection.